Localized CO2 Corrosion of X70 Steel in Water Accumulation Zone of Wet Gas Pipelines

doi:10.11902/1005.4537.2022.296

Journal of Chinese Society for Corrosion and protection

2023, Vol. 43

Issue (4): 837-846 DOI: 10.11902/1005.4537.2022.296

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Localized CO₂ Corrosion of X70 Steel in Water Accumulation Zone of Wet Gas Pipelines

LI Qiang¹(

), LU Cheng², TANG Yinghao³, TANG Jianfeng², LIU Bingcheng¹

^1.Institute of Climate and Energy Sustainable Development, Qingdao University of Science and Technology, Qingdao 266061, China
^2.College of Pipeline and Civil Engineering, University of China Petroleum (East China), Qingdao 266580, China
^3.China Petroleum Pipeline Engineering Corporation, Langfang 065099, China

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Abstract

The free corrosion potential and galvanic corrosion current of different spots of an inclined pipeline were assessed via a home-made device, aiming to simulate the CO₂ induced localized-corrosion emerged at the area with standing water of an inclined pipeline of X70 steel for transporting wet gas, with an electrode composed with a bundle of isolated wires of matrix-like distribution as measuring electrodes. So that to illustrate the relevant localized corrosion mechanism. The results showed that localized corrosion happens for different pipeline structure by different gas flow conditions. What is more, the localized corrosion became more concentrated when the exposure time was elongated. The most severe localized corrosion was seen when the gas flow velocity was 2 m/s and the pipeline had an inclined angle of 30°. Amongst the three factors, including the extent of non-uniformity of water film thickness, frequency of waves arisen by the high velocity gas flow and the formation of corrosion film, that affected the corrosion process, wave frequency and corrosion film had the most influential effect.

Key words: CO₂ localized corrosion water accumulation zone non-steady flow water film X70 steel corrosion product

Received: 24 September 2022 32134.14.1005.4537.2022.296

ZTFLH:

TG174

Fund: Natural Science Foundation of Shandong Province(ZR2019BEE040);Fundamental Research Funds for Central Universities(18CX02001A)

Corresponding Authors: LI Qiang, E-mail: qiangli@qust.edu.cn

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Cite this article:

LI Qiang, LU Cheng, TANG Yinghao, TANG Jianfeng, LIU Bingcheng. Localized CO₂ Corrosion of X70 Steel in Water Accumulation Zone of Wet Gas Pipelines. Journal of Chinese Society for Corrosion and protection, 2023, 43(4): 837-846.

URL:

https://www.jcscp.org/EN/10.11902/1005.4537.2022.296 OR https://www.jcscp.org/EN/Y2023/V43/I4/837

Fig.1 Schematic diagram of CO₂ local corrosion test device in the simulated water accumulation area

Fig.2 Schematic diagram of experimental wire beam electrode

Fig.3 Test results of coupling current at different inclination angles: (a) 15°, (b) 30°, (c) 45°

Fig.4 Flow state of liquid accumulation in tubes with different inclination angles: distribution of water film in the pipe at 15° (a), 30° (b), 45° (c) and frequency of waves flowing through the electrodes at different inclination angles (d)

Fig.5 Test results of coupling current at different gas flow rates: (a) 4 m/s, (b) 6 m/s

Fig.6 Flow state of liquid accumulation in pipes with different gas velocities: distribution of water film in the pipe at 4 m/s (a), 6 m/s (b) and frequency of waves flowing through the electrodes at different gas velocities (c)

Fig.7 Coupling current distribution under different corrosion time: (a) 24 h, (b) 168 h

Fig.8 EIS of electrode wire at typical location (a) and equivalent circuit diagram (b)

Table 1 EIS fitting results of wire beam electrodes at different positions

Fig.9 Corrosion morphology of wire beam electrode C after different corrosion time: (a) fresh surface, (b) 24 h, (c) 168 h

Fig.10 Corrosion morphology of electrode wires at different positions after 168 h corrosion: (a) electrode A, (b) electrode B, (c) electrode C

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